HomeMy WebLinkAboutBRETT 4 - Well Abandonment Report - Kerr McGee - 1/28/2025Casing History
Subsequent Report of Abandonment
Details:
If yes, explain details below
If yes, explain details below
Yes NoWellbore has Uncemented Casing leaks:
NoYesFish in Hole:
1450Estimated Depth:NoYesCasing to be pulled:
Other
Mechanical ProblemsProduction Sub-economicDryReason for Abandonment:
-104.93125340.136814 Longitude:
GPS Data:
Only Complete the Following Background Information for Intent to Abandon
2.5 02/05/2009GPS Quality Value:Date of Measurement:
Latitude:
Type of GPS Quality Value:PDOP
90750Field Number:Field Name:WATTENBERG
Federal, Indian or State Lease Number:
Meridian:667W Range:Township:2N 18Section:QtrQtr:
4 Well Number:
NWSE
County:WELD
Location:
BRETTWell Name:
05-123-16429-00API Number
This form is to be submitted as an Intent to Abandon whenever an abandonment is planned on a borehole. After the
abandonment is complete, this form shall again be submitted as a Subsequent Report of the actual work completed. The
approved intent shall be valid for six months after the approval date, after that period, a new intent will be required.
Attachments required with the Intent to Abandon are wellbore diagrams of the current configuration and the proposed
configuration with plugs set.
A Subsequent Report of Abandonment shall indicate the actual work completed. Attachments required with a Subsequent
Report are a wellbore diagram showing plugs that were set and casing remaining in the hole, the job summaries from all
plugging contractors used, including wireline and cementing (third party verification) and any logs that may have been run
during abandonment.
State of Colorado
Energy & Carbon Management Commission
1120 Lincoln Street, Suite 801, Denver, Colorado 80203 Phone: (303) 894-2100 Fax: (303) 894
-2109
WELL ABANDONMENT REPORT
FORM
6
Rev
11/20
Notice of Intent to Abandon
lorena_ruiz@oxy.comEmail:
Fax:
(970) 336-3535Phone:
Zip:80217-
3779
COState:DENVER
P O BOX 173779
Contact Name:
City:
Lorena Ruiz
Address:
KERR MCGEE OIL & GAS ONSHORE LPName of Operator:
47120ECMC Operator Number:
robbie.revas@state.co.usEmail:
Tel:(720) 661-7242Name:Revas, Robbie For "Intent" 24 hour notice required,
ECMC contact:
10/14/2024
Date Received:
Document Number:
DE ET OE ES
403955502
Formation Perf. Top Perf. Btm Abandoned Date Method of Isolation Plug Depth
CODELL 7504 7520 RETAINER/SQUEEZED 7195
J SAND 7928 7970 BRIDGE PLUG 7550
Total: 2 zone(s)
Current and Previously Abandoned Zones
Type of Well Abandonment Report:
Page 1 of 5Date Run: 11/4/2024 Doc [#403955502] Well Name: BRETT 4
Technical Detail/Comments:
NoYesFlowline/Pipeline has been abandoned per Rule 1105
Type of Cement and Additives Used:
*Cementing Contractor:*Wireline Contractor:
Cut and Cap Date:
inch casingft. of
Additional Plugging Information for Subsequent Report Only
Casing Recovered:
Plug Tagged: Plug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASINGPlug Type:
Plug Tagged:CASING
Plug Tagged:
(Cast Iron Cement Retainer Depth)
CICR Depth
CICR Depth
1730
4275
CICR Depth7195
sacks cmt on top.withCIBP #5: Depth
sacks cmt on top.withsacks cmt on top. CIBP #4: DepthwithCIBP #3: Depth
Set sacks in mouse holeSetsacks in rat hole
NoYesAbove Ground Dry-Hole Marker:Cut four feet below ground level, weld on plate
90Set sacks at surface
ft.618ft. to1450sacks half in. half out surface casing fromSet345
sacks. Leave at least 100 ft. in casing150ft. with2170Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. with4325Perforate and squeeze at
sacks. Leave at least 100 ft. in casing95ft. withPerforate and squeeze at 7225
ft. ft. tosks cmt fromSet
ft. 0ft. to300sks cmt fromSet90
ft. 1570ft. to1730sks cmt fromSet15
ft. 4215ft. to4275sks cmt fromSet5
ft. 7135ft. to7195sks cmt from5Set
sacks cmt on top.300 with 90sacks cmt on top. CIBP #2: Depth2with7550CIBP #1: Depth
Plug Type:
NOTE: Two(2) sacks cement
required on all CIBPs.
Plugging Procedure for Intent and Subsequent Report
Casing Type Size of
Hole
Size of
Casing
Grade Wt/Ft Csg/Liner
Top
Setting
Depth
Sacks Cmt Cmt Btm Cmt Top Status
SURF 12+1/4 8+5/8 J55 24 0 668 470 300 0 VISU
1ST 7+7/8 4+1/2 I80 11.6 0 7612 575 7612 3720 CBL
1ST LINER 7+7/8 2+7/8 N80 6.5 7578 8125 35 8145 7570 CBL
Surface Plug Setting Date:
Number of Days from Setting Surface Plug
to Capping or Sealing the Well:
Page 2 of 5Date Run: 11/4/2024 Doc [#403955502] Well Name: BRETT 4
5/3/2025Expiration Date:
BMPs:
Signage for P&As:
Prior to commencing operations, KMG will post signs in conspicuous locations. The signs will indicate plugging and abandonment
operations are being conducted, the well name, well, and the Operator’s contact information. Signs will be placed so as not to create
a potential traffic hazard.
Notifications:
Courtesy notifications will be sent to all parcel owners with building units within 1,500 feet of the location letting them know about out
plugging and abandonment operations and providing contact information for Kerr McGee's response line and online resources.
Wellbore Pressure:
In some cases, wellbore pressure drawdown operations may occur approximately 1-2 days prior to Move In Rig Up (MIRU) of the
workover rig. This is conducted to allow for reduced time that the workover rig is needed on location. These operations will be
conducted in accordance with Form 4 and/or Form 6 requirements.
Water:
Water will be placed on dirt access roads to mitigate dust as needed.
Lighting:
Operations are daylight-only; no lighting impacts are anticipated from operations.
Noise:
Operations will be in compliance with Table 423-1 requirements. Based off the rig sound signature, rig orientation will be considered
to reduce noise levels to nearby building units.
Environmental Concerns:
This location was reviewed using a desktop method to review publicly available wildlife data (including CPW & ECMC data) as well
as internal wildlife datasets and aerial imagery. All field personnel are trained to identify wildlife risks and raise concerns noticed
during operations with the KMOG Health, Safety, and Environment (HSE) department.
JENKINS, STEVE
Based on the information provided herein, this Well Abandonment Report (Form 6) complies with ECMC Rules and applicable
orders and is hereby approved.
ECMC Approved:Date:11/4/2024
I hereby certify all statements made in this form are, to the best of my knowledge, true, correct, and complete.
Signed:Print Name:Christina Hirtler
Title:Regulatory Date:10/14/2024 Email:christina_hirtler@oxy.com
CONDITIONS OF APPROVAL, IF ANY LIST
Page 3 of 5Date Run: 11/4/2024 Doc [#403955502] Well Name: BRETT 4
COA Type Description
FLOWLINE AND SITE CLOSURE
1) Consistent with Rule 911.a, a Form 27 must be approved prior to cut and cap,
conducting flowline abandonment, or removing production equipment. Allow 30 days for
Director review of the Form 27; include the Form 27 document number on the Form 44
for offsite flowline abandonment (if applicable) and on the Form 6 Subsequent.
2) Properly abandon flowlines per Rule 1105. If flowlines will be abandoned in place,
include with the Form 27: pressure test results conducted in the prior 12 months as well
as identification of any document numbers for a ECMC Spill/Release Report, Form 19,
associated with the abandoned line.
1) Provide 2 business day notice of plugging MIRU via electronic Form 42, and provide
48 hours Notice of Plugging Operations, prior to mobilizing for plugging operations via
electronic Form 42. These are 2 separate notifications, required by Rules 405.e and
405.I.
2) Prior to placing the 1450’ plug: verify that all fluid migration (liquid and gas) has been
eliminated. If evidence of fluid migration or pressure remains, contact ECMC Engineer
for an update to plugging orders.
3) After isolation has been verified, pump surface casing shoe plug. If cement is not
circulated to surface, shut-in, WOC 4 hours then tag plug – must be at 618’ or shallower
and provide 10 sx plug at the surface.
4) Leave at least 100’ of cement in the wellbore for each plug without mechanical
isolation.
5) After surface plug and prior to cap, verify isolation by either a 15 minute bubble test
or 15 minute optical gas imaging recording. If there is indication of flow contact ECMC
Engineering. Provide a statement on the 6SRA which method was used and what was
observed. Retain records of final isolation test for 5 years.
6) With the Form 6 SRA operator must provide written documentation which positively
affirms each COA listed above has been addressed.
Prior to starting plugging operations a Bradenhead test shall be performed if there has
not been a reported Bradenhead test within the 60 days immediately preceding the start
of plugging operations.
1) If, before opening the Bradenhead valve, the beginning pressure is greater than 25
psi, sampling is required.
2) If pressure remains at the conclusion of the test, or if any liquids were present during
the test, sampling is required.
The Form 17 shall be submitted within 10 days of the test. Sampling shall comply with
Operator Guidance - Bradenhead Testing and Reporting Instructions. If samples are
collected, copies of all final laboratory analytical results shall be provided to the ECMC
within three (3) months of collecting the samples.
3 COAs
ATTACHMENT LIST
Att Doc Num Name
403955502 WELL ABANDONMENT REPORT (INTENT)
403955525 PROPOSED PLUGGING PROCEDURE
403955526 WELLBORE DIAGRAM
403980884 FORM 6 INTENT SUBMITTED
Total Attach: 4 Files
Page 4 of 5Date Run: 11/4/2024 Doc [#403955502] Well Name: BRETT 4
User Group Comment Comment Date
Engineer 1) Deepest Water Well within 1 mile = 532’.
2) Fox Hills Bottom- 359’, per SB5.
11/04/2024
OGLA Location Assessment review complete.11/04/2024
OGLA Operator will implement measures to capture, combust, or control emissions to protect
health and safety, and to ensure that vapors and odors from well plugging operations do
not constitute a nuisance or hazard to public health, welfare and the environment. Due to
the proximity of residential building units (RBUs) all blowdown gasses will be controlled.
11/04/2024
OGLA COA's provided by the operator as Best Management Practices under Technical Detail /
Comments:
Signage for P&As:
Prior to commencing operations, KMG will post signs in conspicuous locations. The signs
will indicate plugging and abandonment operations are being conducted, the well name,
well, and the Operator’s contact information. Signs will be placed so as not to create a
potential traffic hazard.
Notifications:
Courtesy notifications will be sent to all parcel owners with building units within 1,500 feet
of the location letting them know about out plugging and abandonment operations and
providing contact information for Kerr McGee's response line and online resources.
Lighting:
Operations are daylight-only; no lighting impacts are anticipated from operations.
Noise:
Operations will be in compliance with Table 423-1 requirements. Based off the rig sound
signature, rig orientation will be considered to reduce noise levels to nearby building units.
Environmental Concerns:
This location was reviewed using a desktop method to review publicly available wildlife
data (including CPW & ECMC data) as well as internal wildlife datasets and aerial
imagery. All field personnel are trained to identify wildlife risks and raise concerns noticed
during operations with the KMOG Health, Safety, and Environment (HSE) department.
11/04/2024
Permit selected PDOP from dropdown box
Verified as drilled lat/long
Verified completed intervals - 799816
Verified production reporting
pass
10/14/2024
Total: 5 comment(s)
General Comments
Page 5 of 5Date Run: 11/4/2024 Doc [#403955502] Well Name: BRETT 4
OCCCCIDENTAL PETROLEUM CORPORATION
Please contact yourur area engineer with any quesestitions concncerningng this procedure.e.
9/13/2024
PLUGUG and ABANDODONMENENT PROCEDURE
BRETT 4 API:I: 05-123-16429
Step Description
1 Review Previous Open Wells Reports/Well History. If you have questions or concerns, contact Foreman/Engineer.
2 COA: Provide 48 hour notice to Colorado ECMC prior to rig up per request on approved Form 6 (e.g. call field coordinator, submit
Form 42, etc.).
3 Notify Automation Removal Group at least 24 hours prior to rig move. Request they catch and remove plunger, isolate production
equipment, and remove any automation prior to rig MIRU.
4 MIRU Slickline. Pull production equipment and tag bottom. Record tag depth, casing/tubing pressures and fluid level in Open Wells.
Gyro was run on 10/15/14. RDMO Slickline.
5 Prepare location for base beam equipped rig. Install perimeter fence as needed.
6 COA: Verify Form 17 (State Bradenhead Test) has been run within 60 days of RU.
7 Refer to the Rockies Well Services Guidelines document whenever rigging up BOP and WL, or whenever tripping in or out of the
well. Consult with Foreman/Engineer before deviating from these guidelines.
8
Upon RU, check and record bradenhead pressure. If bradenhead valve is not accessible, re-plumb so that valve is above GL. Blow
down bradenhead and leave open during working hours. Re-check pressure each day and input value in the "Casing press." box in
Open Wells.
9 MIRU
1010
MIRU WO rig. Verify BOP and wellhead rating, inspect for appropriate API standards, pressure test BOP. Kill well as necessary using
biocide treated fresh water. ND WH. NU BOP. Unland tbg. Release packer set at 7180'. **Barrier Management** Fluid will be the
only barrier while NU BOP. Stop and review JSA.
1111 TOOH and SB 7195' of 2-3/8" tbg. LD remaining 2-3/8" tbg. LD packer and 2-3/8" tbg.
1212 MIRU WL. PU and RIH with (4-1/2", 11.6#) gauge ring to 7560'. POOH.
1313 PU and RIH with (4-1/2", 11.6#) CIBP and set at +/- 7550' . POOH. RIH and dump 2 sx cement on CIBP. POOH.
1414 NIO INJECTION SQUEEZE
1515 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 7225'. POOH. RDMO WL.
1616 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 7195'.
1717
MIRU cementers. Make sure the tubing annulus is loaded with water then attempt to establish injection max pressure 6160 psi with
water. If it won't inject then sting out, load tubing with cement a bbl short of EOT then sting back in, in the next step. Max
pressure is 3365 psi with tubing full of cement unless pressure is applied to annulus.
1818
Pump Niobrara Injection Squeeze: 100 sx (27.1 bbl or 152 cf) of the Niobrara Cement blend: Class G with 0.4% B547 Gas Block
(Latex) and 0.4% D255 FLA (Fluid Loss) and 35% D066 Silica Flour and 0.2% D800 (Retardant) and 0.3% D065 (Dispersant).
Underdisplace by 1 bbls. Volume is based on 30' in the casing below the CICR, cement squeezed into formation, and 60' on top of
the CICR. Collect wet and dry samples of cement to be left on rig. RDMO cementers.
1919 Pull out of cement and reverse clean with 2x bottoms up. TOOH, SB 4275' of 2-3/8" tbg. LD remaining tbg.
2020 SUSSEX INJECTION SQUEEZE
2121 PU and RIH with one 4', 3-1/8'' deep penetrating perf gun wth 4 spf. Shoot squeeze holes at 4325'. POOH. RDMO WL.
2222 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 4275'.
2323
MIRU cementers. Make sure annulus is full of water then attempt to establish injection with water, max pressure is 3963 psi, pipe is
light at max. If it won't inject then sting out and load tubing with cement a bbl short of EOT then sting back in, in the next step.
Max pressure is 3449 psi,with tubing full of cement, pipe is light at max.
24
Pump Sussex Squeeze: 100 sx (21.2 bbl or 119 cf) of the Sussex AGM: Class G with 0.4% B547 Gas Block (Latex) and 2% D053
Expansion (Gyp) and 0.25% D255 FLA (Fluid Loss)0.3% D065 (Dispersant). Underdisplace by 1 bbls. Volume is based on 50' in the
casing below the CICR, cement squeezed into formation, and 60' on top of the CICR. Collect wet and dry samples of cement to be
left on rig. RDMO Cementers.
25 Move up above cement top and reverse circulate 2X Bottoms up. TOOH and SB 1730' of 2-3/8" tbg. LD stinger, and remaining tbg.
26 UPPER PIERRE ROLL-OVER
27 MIRU WL. PU and RIH with two 4', 3-1/8'' perf guns with 4 spf. Shoot 16 squeeze holes at 2170' and 16 squeeze holes at 1670'.
RDMO WL.
28 PU and TIH with (4-1/2", 11.6#) packer on 2-3/8" tbg. Set packer at 1730'.
29 Initiate circulation at low rate monitoring returns for fluid. Add mud thinner to hydrate/clean mud. Slowly increase circulation rate
to 4-6 BPM using mud thinner and gel polymer sweeps as needed.
30 Pump 36 bbls of 160F HSF (0.5 gals/bbl or 1.5 lbs/bbl) and let soak for ~2 hours.
31 Continue circulating at 4-6 BPM if possible. If returns show hydrocarbons or a 1 hr build-up shows pressure, swab and vent well and
clean open tank. Circulate clean fluid before pumping cement.
32 Release packer. TOOH, SB 2-3/8" tbg. LD packer.
33 PU and TIH with (4-1/2", 11.6#) CICR on 2-3/8" tbg. Set CICR at 1730'.
34
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Squeeze: 165 sx (35.6 bbl or 200 cf)
of the Lower AGM blend: Class G with 0.4% B547 Gas Block (Latex) and 1% S001 CC (Calcium Chloride) and 4% D053 Expansion
(Gyp). Underdisplace by 2.5 bbls. Volume is based on 440' in the casing below the CICR, 500' in the casing-hole annulus with 25%
excess, and 160' on top of the CICR. Collect wet and dry samples of cement to be left on rig. RDMO Cementers.
35
36 TOOH and SB 1450' of 2-3/8" tbg. LD stinger, and remaining tbg.
37 COA: WOC 8 hours. If there is evidence of pressure or fluid migration, contact Engineering as there will need to be additional
remediation attempts before the SC shoe plug.
38 CUT AND PULL CASING
39 PU and TIH with mechanical cutter on 2-3/8" tbg. Cut 4-1/2", 11.6# casing at 1450'. TOOH and LD cutter.
40 Attempt to establish circulation with biocide treated fresh water. Circulate in 71 bbls of HSF and displace to the cut. Soak for 1+
hr then circulate out. This will cover all remaining HSF needs for this well.
41 ND BOP. ND TH. Un-land casing. Rig max pull shall be 100,000#. Max pull over string weight shall be 50,000#. If unable to unland,
contact Foreman/Engineer. **Barrier Management** Fluid will be the only barrier while unlanding casing. Stop and review JSA.
42 Install BOP on casing head with 4-1/2", 11.6# pipe rams. **Barrier Management** Fluid will be the only barrier while NU BOP. Stop
and review JSA.
43 TOOH and LD all 4-1/2", 11.6# casing. Remove 4-1/2", 11.6# pipe rams and install 2-3/8" pipe rams.
44 SHOE PLUG
45 TIH with 2-3/8" tubing to 1450'. Establish circulation to surface with biocide treated fresh water.
46 Initiate circulation at low rate monitoring returns for fluid. Add mud thinner to hydrate/clean mud. Slowly increase circulation rate
to 4-6 BPM using mud thinner and gel polymer sweeps as needed.
47 Continue circulating at 4-6 BPM if possible. If returns show hydrocarbons or a 1 hr build-up shows pressure, swab and vent well and
clean open tank. Circulate clean fluid before pumping cement.
48 COA: Verify and document that all pressure and fluid migration has been eliminated prior to placing the SC shoe plug at 1450'. If
there is evidence of pressure or fluid migration, contact Engineering.
49
MIRU cementers. Pump 10 bbls (min) of pre-flush, followed by 5 bbls fresh water spacer. Pump Surface Casing Shoe Plug: Pump 345
sx (74.4 bbl or 418 cf) of the Upper AGM blend: Class G with 0.4% B547 Gas Block (Latex) and 1.5% S001 CC (Calcium Chloride) and
4% D053 Expansion (Gyp). Volume is based on 782' in 7.875" bit size open hole with 30% excess factor. 203' in the 8-5/8", 24#
surface casing with no excess. The plug is designed to cover 1450'-465'. Plug length exceeds 500'. Consult with Foreman or
Engineer on splitting up the plug. Collect wet and dry samples of cement to be left on rig. RDMO Cementers. Notify engineering if
circulation is ever lost during job.
50 COA: If cement was not circulated to surface, then WOC 4 hours. Tag TOC. TOC must be 618' or shallower. If tag is too deep or
there is evidence of pressure or fluid migration, contact Engineering.
51 Pull out of cement. TOOH to 300'. Circulate tbg clean with fresh water. TOOH & SB 300' of tubing. WOC 4 hours.
52 Note: Plug can be tagged after a 4 hour WOC, but must have a 6 hour WOC prior to pressure testing.
53 ND 7-1/16" BOP. NU 9" or 11" BOP. RIH with bit and scraper. Clean csg and tag TOC. Circulate Clean. POOH. PT casing to 500 psi.
Contact engineering if test fails.
54 SURFACE PLUG
55 PU and RIH with (8-5/8", 24#) CIBP and set at 300'. POOH.
56 TIH with 2-3/8" tubing to 300' .
57
MIRU Cementers. Pump Surface Plug: Pump 90 sx (19.4 bbl or 109 cf) of the Surface AGM blend: Class G with 0.4% B547 Gas Block
with no excess. Cement will be from 300' to surface. Verify and document cement to surface. Collect wet and dry samples of
cement to be left on rig.
58 TOOH and insert ~5' of 2-3/8" Tbg. Circulate FW to clean Csg & Csg Valves. LD final joint of 2-3/8" Tbg. RDMO cementers. ND BOP.
Install night cap. RDMO WO rig.
59 Instruct cementing and wireline contractors to e-mail copies of all job logs/job summaries to DJVendors@oxy.com within 24 hours
of completion of the job.
60 Supervisor submit paper copies of all invoices, logs, and reports to Well Services Engineering Specialist.
61 Excavation crew to notify One Call to clear excavation area around wellhead and for flow lines.
62
63 Welder cut casing minimum 5' below ground level.
64 Spot weld on steel marker plate. Marker should contain Well name, Well number, legal location (1/4 1/4 descriptor) and API
number.
65 Obtain marker plate GPS location data and provide to GPS Teams page and Oxy GIS database.
66 If applicable, abandon flow lines per Rule 1105. File electronic Form 42 and/or Form 44 once abandonment is complete.
67 Back fill hole with fill. Clean location, and level.
68 Submit Form 6 Subsequent Report to CECMC ensuring to provide 'As performed' WBD identifying operations completed.
Deepest WW 1 mile: 532'; FHM: 955'; Sussex Top: 4309'; Sussex Base: 4536'; Shannon Base: 4900'; Niobrara Top: 7240'
WELL HAS GYRO. Gyro was run on 10/15/14.
No known casing integrity issues.
SUSSEX/SHANNON PRODUCTIVE WITHIN 1 MILE
Well was drilled by .
Vertical Well.
API: 05-123-16429 CREATED BY:T. Nicosia DATE:Sep 13, 2024
WELL NAME: BRETT 4 ELEVATION: 4961 QTRQTR:NWSE
COUNTY:WELD GROUND LEVEL: 4950 SEC:1818
LATITUDE:40.1368181 MD:8145 TWN:2N2N
LONGITUDE:-104.931225 PBMD:8089 RNG:67W
Existing DATUM: RKB Proposed
KB=11'
Hole Size/Depth 12-1/4" / 680'90 sx cmt to surface
1.21 yld
Deepest water well in 1 mile - 532'300'
470 Sx Cmt
Surface Casing 8-5/8", 24#, J-55 set @ 668'345 sx 618'TOC
1.21 yld
1450'BOC
1450'Cut casing
Upper Pierre Aquifer Base 1470'
15 sx 1570'TOC in csg
1670'Perfs/TOC
1730'
150 sx
1.21 yld 2170'Perfs/BOC
TOC (from CBL)3720'
Sussex Productive in 1 mile 5 sx 4215'TOC in csg
Top 4309'4275'
Base 4536'95 sx 4325'Perfs/BOC
Shannon Base 4900' - Productive in 1 mile
200 Sx Cmt: Stage 2
BOC (from CBL)5160'
TOC (from CBL)6412'
5 sx 7135'TOC in csg
Niobrara Top 7240'7195'
95 sx 7225'Perfs/BOC
New Cement
Codell Perfs 7504' - 7520'Existing Cement
575 Sx Cmt Liner Hanger @ 7578'2 sx New CICR
Production Casing 4-1/2", 11.6#, I-80 set @ 7612'7550'Existing CICR
Hole Size/Depth 7-7/8" / 7632'New CIBP
TOC (from CBL)7570'Existing CIBP
J Sand Perfs 7928' - 7970'Treated Water
3535 Sx Cmt Brine
Liner Casing 2-7/8", 6.5#, N-80 set @ 8125'Mud
Hole Size/Depth 3-7/8" / 8145'Sand Plug